27 results about "Vertical seismic profile" patented technology

The invention relates to a DAS-VSP seismic data reconstruction method based on a multi-scale attention network, and belongs to a reconstruction method based on DAS-VSP missing data in a well. Comprising the following steps: constructing a vertical seismic profile data set, constructing and training a multi-scale attention network, and realizing seismic data reconstruction by using lacked-channel DAS-VSP data. The method has the advantages that a multi-scale network is adopted as a backbone network, potential feature information of different scales is dynamically extracted and fused from DAS-VSP data containing noise and missing, and the accuracy of a reconstruction result is enhanced; a local attention module is introduced, a network is focused on related features of DAS-VSP reconstruction signals through a self-attention mechanism, the reconstruction precision of data is improved, the performance defects of a traditional method are effectively overcome, the reconstruction precision is remarkably improved, a reliable basis is provided for follow-up analysis and explanation work of DAS-VSP data, and the method is suitable for popularization and application. And the recognition degree and the application value of the DAS-VSP technology in the field of oil-gas exploration are improved.

A computer-implemented method includes: accessing wireline data and vertical seismic profiling (VSP) data; correlating logged velocity from the wireline data with velocity data from the VSP data to calibrate the logged velocity; determining, based on, at least in part, the calibrated logged velocity, a range of incidence angles for acquiring seismic traces sufficient to map a formation depth at the geo-exploration site using pairs of acoustic emitter and acoustic receiver placed at a surface of the geo-exploration site; and determining a range of offsets between the acoustic emitter and the acoustic receiver of each pair so that the acoustic receiver can acquire seismic traces sufficient to map the formation depth at the geo-exploration site; and comparing the range of angles and the range of offsets with acquisition parameters of a planned seismic survey to determine whether the planned seismic survey can map as deep as the formation depth.

The application discloses a kind of vertical seismic profile up-and-down wave intelligent separation methods based on data driving, comprising the following steps: S1: collection well logging data, including velocity information and density information;S2: establish formation model and define seismic observation system, then based on vertical seismic profile wave field propagation equation numerical simulation, obtain simulated up-and-down wave data, and combined to obtain simulated total wave field data;S3: establish the neural network of multi-task learning, according to the data obtained in step S2 the neural network is trained, and obtains regression model;S4: carry out feasibility test, when the result is not up to standard, adjust training sample and optimize network parameter, return step S3 and retrain;When the result is up to standard, the regression model obtained in step S3 is used as the final separation model, and the target vertical seismic profile data is separated into up-and-down wave using it.The application can more intelligently, efficiently and accurately separate the up-and-down wave of vertical seismic profile data.

The invention discloses a gas reservoir three-dimensional geological modeling method and system and a medium. The method comprises the following steps: acquiring multi-source data of a target work area; in combination with vertical seismic section data and virtual well data, depth correction is performed on the horizon after time-depth conversion, and a three-dimensional tectonic framework model is established based on the corrected horizon and fault data; fusing and generating a sand body space development probability trend body based on the seismic attribute body, the seismic inversion body and the determined optimal weight coefficients of the seismic attribute body and the seismic inversion body; a three-dimensional tectonic framework model is used as a space framework, a sand body space development probability trend body is used as a transverse soft constraint, a plurality of isoprobable lithofacies model initial implementation is established, and a three-dimensional lithofacies model is obtained; a three-dimensional distribution model of reservoir physical property parameters is generated; and importing the three-dimensional lithofacies model and the three-dimensional distribution model into a numerical simulator, performing historical fitting by using gas reservoir dynamic production data, analyzing fitting differences, and performing iterative modeling to obtain a high-precision and low-uncertainty three-dimensional gas reservoir geologic model.

The invention discloses an average velocity body construction method and device, electronic equipment and a storage medium. The method comprises the following steps: determining seismic data of a target area and vertical seismic section time-depth data of each target drilling well; based on the seismic data of the target area, generating a first seismic average velocity body corresponding to the target area; determining a first time-depth relationship of each target drilling well; based on the vertical seismic profile time-depth data of each target drilling well, adjusting the first time-depth relationship of each target drilling well to obtain a second time-depth relationship; generating a second earthquake average velocity body according to the second time-depth relationship; and determining at least one target error value according to the first seismic average velocity body and the second seismic average velocity body, and adjusting the first seismic average velocity body to obtain a target seismic average velocity body of the target area. According to the technical scheme, the precision of the seismic average velocity body corresponding to the region can be improved.

The invention discloses a biased VSP missing data reconstruction method and device based on 2D FFT, electronic equipment and a medium. The method may include: sorting biased VSP data into a plurality of common geophone gathers; constructing a sparse sampling operator for the common detection point gather; and obtaining missing data aiming at the data reconstructed through common detection point gather iteration. The method is suitable for missing data reconstruction of the biased vertical seismic section, data can be effectively complemented, and the influence of insufficient underground illumination caused by the missing data is relieved.

To provide full automation of high-resolution interval velocity estimation for check-shot and other vertical seismic profile-type datasets.SOLUTION: A method includes the steps of: disposing sensors within a borehole; disposing seismic sources on a surface away from a wellhead of the borehole at a field location; propagating seismic waves using the seismic sources; obtaining particle velocity data from geological stratum in the field location; obtaining strain data from the geological stratum in the field location; performing a peak-to-peak amplitude analysis for the particle velocity data for a target phase; performing a peak-to-peak amplitude analysis for the strain data for the target phase; and estimating a velocity of waves in the geological stratum based upon the peak-to-peak amplitude analysis for the particle velocity data for the target phase and the peak-to-peak amplitude analysis for the strain data for the target phase.SELECTED DRAWING: None

The invention discloses a three-dimensional VSP and ground seismic joint migration method, system and device and a storage medium, and relates to the technical field of seismic exploration, and the method comprises the steps: obtaining vertical seismic section data and ground seismic data, and obtaining a preprocessed data body; performing isotropic migration velocity modeling on the two sets of data volumes to obtain respective imaging gathers and migration profiles; performing unification processing on the imaging reference surfaces of the two sets of data volumes to obtain a processed imaging gather; performing well-ground joint migration on the processed imaging gather to obtain a well-ground joint OVT domain imaging gather; and azimuth anisotropy correction of travel time is carried out on the well-ground combined OVT domain imaging gathers, superposition processing is carried out on the corrected imaging gathers, and finally a well-ground combined migration imaging profile is obtained. According to the invention, effective fusion and high-precision imaging of well-ground data are realized, and the imaging precision of seismic data and the success rate of oil-gas exploration are improved.

Systems and methods for determining a calibrated vertical seismic profile (VSP) using a distributed acoustic sensing (DAS) system in a borehole are presented. The method includes obtaining a density log and an acoustic slowness log of the borehole (108); determining a first impedance from the density logging curve and the acoustic slowness logging curve, i.e., a DAS impedance (DIL) curve from the logging curve; obtaining a VSP data set in the borehole (108); for each of the plurality of gauge lengths, a second impedance, i.e. A DAS (DIV) curve from vibration, is determined from the VSP dataset of the plurality of gauge lengths, and a fit between the DIV curve and the DIL curve is determined by using a mismatch functional for each of the plurality of depth adjustments. The method also includes determining a calibrated VSP by applying the preferred depth adjustment to the VSP dataset.

This disclosure relates to a method for detecting fracture zones in hot dry rock, a method for determining drilling trajectories, and a system. The detection method includes: determining the fracture length and extension direction of the fracture zone using a surface direct current potential method; determining the top surface of the fracture zone using a variable offset vertical seismic profiling method; determining the three-dimensional dip angle of the fracture surface relative to the fracture initiation point based on the extension direction and the fracture initiation point; and determining the spatial distribution range of the fracture zone based on the top surface, the three-dimensional dip angle, and the fracture length. The technical solution provided by this disclosure can combine the surface direct current potential method and the variable offset vertical seismic profiling method to achieve full-element spatial detection of fracture zones, thereby providing data support for the trajectory design of the second directional well in a hot dry rock geothermal resource development well group, and facilitating the establishment of effective artificial heat exchange channels during the development of hot dry rock geothermal resources.

The invention discloses a vertical seismic section data denoising method and device, and the method comprises the steps: carrying out the forward modeling of an elastic wave wave equation through employing a plurality of forward modeling geologic models and different forward modeling simulation parameters, generating different types of synthetic vertical seismic section data sets, extracting different types of noises, and constructing a training data set; adopting the training data set to train the vertical seismic profile data denoising model; after actual vertical seismic section data is obtained, inputting the trained vertical seismic section data denoising model to obtain denoised vertical seismic section data; the vertical seismic profile data denoising model comprises a convolution layer used for carrying out feature extraction on a training data set; the self-adaptive feature weight distribution module is used for carrying out self-adaptive weight correction on the extracted features; the down-sampling module is used for down-sampling the features after weight correction; the up-sampling module is used for carrying out noise suppression on the down-sampling features of different sizes. The method is good in noise suppression effect and high in denoising precision.

In the field of seismic data collection and analysis, the problem of data compression is considered. It is desired to reduce the storage and transmission requirements of seismic data, such as associated with microseismic monitoring and processing, VSP (vertical seismic profile) surveys, and the like, for instance using a distributed acoustic sensor (DAS), which can generate in excess of 50 GB of data per hour on a survey that lasts days. A method and system for data compression that separates the data collected into additive signal and noise components, and compresses the estimated signal component for transmission, storage, and analysis, is described. The idea is that the signal component, which exhibits clear structure across the traces, may be accurately described with relatively few parameters, and therefore may be significantly compressed without loss of important information.

The invention discloses a dynamic and static combined migration monitoring and safety early warning method and device and a storage medium, and relates to the technical field of oil and gas field development and engineering monitoring. The method comprises the following steps: constructing a static geological model based on three-dimensional seismic exploration data and non-seismic geophysical data, and performing multi-dimensional analysis on the static geological model to obtain geological risk factors; based on the vertical seismic profile data and the microseismic data of the time-shifted well, constructing a dynamic geologic model, and performing multi-dimensional analysis on the dynamic geologic model to obtain dynamic parameters; the static geologic model and the dynamic geologic model are fused and subjected to joint inversion, and a migration path model is generated to predict the migration direction; and setting a comprehensive early warning threshold value, and triggering graded early warning when the dynamic parameters exceed the comprehensive early warning threshold value. According to the invention, accurate prediction of the migration path and active early warning of storage safety are realized.

The present invention provides a comprehensive interpretation method, device, electronic device and storage medium for seismic exploration, which relates to the field of geophysical exploration. The method comprises: first, inputting target data and drawing parameters, and extracting depth-time data from the vertical component of vertical seismic profile data. Then, the target data is loaded with depth-time data, and a time domain interpretation map and a depth domain interpretation map are generated according to the drawing parameters. Finally, a comprehensive interpretation map of surface seismic and well detection is generated according to the time domain interpretation map and the depth domain interpretation map. In the present invention, the comprehensive interpretation map of surface seismic and well detection is drawn in a pattern combining the time domain interpretation map and the depth domain interpretation map, so that the user can intuitively compare the seismic reflection characteristics of a certain time or time period with the characteristics of the well logging curve and the lithology of the well logging, thereby achieving the purpose of comprehensive interpretation of multiple methods.

The application discloses a seismic wave quality factor Q value inversion method, which comprises the following steps: obtaining target well vertical seismic profile VSP seismic data, picking up downgoing wave first arrival time, extracting downgoing wave field data through wave field separation; determining an analysis time window of each depth sampling point according to the first arrival time, intercepting a corresponding amplitude sequence, and then obtaining dynamic seismic wave length and total seismic wave energy of each depth point; calculating Q values of adjacent depth sections based on a depth interval of adjacent depth sampling points, a dynamic wavelength of an upstream depth point and total energy of the two points, and constructing a target formation Q value inversion model. The application breaks through the limitation of the fixed wavelength assumption, greatly improves the stability and precision of Q value inversion of complex formations, and adapts to deep reservoir exploration requirements.

The embodiment of the invention discloses a well-ground combined mining seismic data combined imaging method, device and equipment and a medium. The method comprises the following steps: constructing a scattering model for a to-be-imaged block, and performing forward modeling on the scattering model to obtain a corresponding seismic record; the scattering model is a model used for simulating the geology of a to-be-imaged block; performing imaging processing on the seismic record to determine a sensitivity compensation function, and determining a target functional according to the sensitivity compensation function; processing the vertical seismic profile seismic data of the to-be-imaged block to obtain a first reflected wave, and processing the ground seismic data of the to-be-imaged block to obtain a second reflected wave; and performing joint imaging on the to-be-imaged block according to the sensitivity compensation function, the target functional, the first reflected wave and the second reflected wave. By adopting the technical scheme provided by the embodiment of the invention, the problems of non-uniformity of coverage times and non-uniformity of incident angles during combined imaging are solved, so that the imaging quality of a geological structure is improved.

The invention provides a rock stratum velocity model establishing method and device, electronic equipment, a medium and a product. The method comprises the following steps: acquiring the root mean square amplitude of each first test position in a target rock stratum; obtaining the measured vertical seismic section speed and acoustic logging speed of each first test position; according to the root-mean-square amplitude of each first test position and the vertical seismic profile velocity and acoustic logging velocity of each first test position, obtaining a characteristic relationship between the root-mean-square amplitude and the rock stratum velocity; based on the characteristic relation, according to the root mean square amplitude of each second test position of the target rock stratum, obtaining the rock stratum velocity; and establishing a rock stratum velocity model of the target rock stratum according to the rock stratum velocity. According to the scheme, the accuracy of the rock stratum velocity modeling result can be improved.

The invention discloses a wave field imaging method and device, electronic equipment and a readable storage medium, and belongs to the technical field of geological exploration. The method comprises the following steps: acquiring ground seismic data and vertical seismic profile data; correcting the reference surface parameter of the ground seismic data and the reference surface parameter of the vertical seismic section data to obtain a target reference surface parameter; acquiring first coordinate data of a plurality of target detection points and second coordinate data of a plurality of target seismic sources based on the target reference plane parameters; and determining target wave field imaging of the geological section according to the multiple pieces of first coordinate data, the multiple pieces of second coordinate data, the ground seismic data and the vertical seismic section data. The target wave field imaging has the characteristics of uniform imaging, large imaging range and high resolution, so that the target wave field imaging quality is relatively high.

The application relates to a time matching method and device for ground seismic P-wave converted wave data, which comprises the following steps: obtaining vertical seismic profile data, ground seismic P-wave data and ground seismic converted wave data; according to the vertical seismic profile data, solving a P-wave interval velocity curve and a S-wave interval velocity curve at a well point position; processing the vertical seismic profile data to separate out vertical seismic P-wave data and vertical seismic converted wave data; performing seismic inversion, analysis and calculation on the P-wave and S-wave interval velocity curves, the vertical seismic P-wave data and the vertical seismic converted wave data to obtain a relationship formula of P-wave velocity and S-wave velocity; combining the P-wave interval velocity curve at the well point position and ground seismic P-wave velocity data obtained by inverting the ground seismic P-wave data to further calculate ground seismic S-wave velocity; and finally converting the converted wave to P-wave two-way travel time according to the ground seismic P-wave velocity, the ground seismic S-wave velocity and the ground seismic converted wave data.

The invention discloses a time-depth relation correction method and device based on VSP data, and the method comprises the steps: obtaining vertical seismic profile data and acoustic logging data which have an incidence relation; determining a time-depth relation curve corresponding to the vertical seismic profile data, and determining an interval transit time curve corresponding to the acoustic logging data; and correcting the interval transit time curve through the time-depth relation curve. The problem that the interval transit time curve is abnormal or deviated due to the fact that the wave logging data are affected by multiple factors is solved.

Systems and methods are presented for determining a calibrated vertical seismic profile (VSP) with a distributed acoustic sensing (DAS) system in a borehole. The methods include obtaining a density log and an acoustic slowness log for the borehole; determining a first impedance, a DAS impedance from well log (DIL) curve, from the density log and the acoustic slowness log; obtaining a VSP dataset in the borehole; for each of the plurality of gauge lengths: determining a second impedance, a DAS from vibrations (DIV) curve, from the VSP dataset for the plurality of gauge lengths, and determining a fit between the DIV curves and the DIL curve by using a misfit functional for each of a plurality of depth adjustments. The method further includes determining the calibrated VSP by applying a preferred depth adjustment to the VSP dataset.

The application provides an elastic wave full waveform inversion method based on a vertical seismic profile, and the method comprises the following steps: obtaining original shot gather data; performing horizontal component rotation on a first original component and a second original component to obtain a first radial component and a tangential component; performing wave field separation on a third original component and the first radial component based on multi-channel vector median filtering to obtain a first downgoing wave, a second downgoing wave, a first upgoing wave and a second upgoing wave; performing amplitude compensation on the first downgoing wave, the second downgoing wave, the first upgoing wave and the second upgoing wave, and then stacking to obtain a fourth original component and a second radial component; and performing consistency correction on the fourth original component and the second radial component based on a root mean square value to obtain a target original component and a target radial component. The application improves the accuracy and reliability of subsequent elastic wave full waveform inversion through a fine pretreatment step.

A method for establishing a formation velocity model, comprising: acquiring a root-mean-square amplitude of each first test location in a target formation (S101); acquiring a measured vertical seismic profile velocity and a measured acoustic logging velocity of each first test location, and on the basis of the root-mean-square amplitude of each first test location and the vertical seismic profile velocity and acoustic logging velocity of each first test location, obtaining a characteristic relationship between root-mean-square amplitudes and formation velocities (S102); and on the basis of the characteristic relationship, and the root-mean-square amplitude of each second test location in the target formation, obtaining formation velocities, and on the basis of the formation velocities, establishing a formation velocity model for the target formation (S103). Further provided are an apparatus for establishing a formation velocity model, and an electronic device and a product. Thus, the accuracy of formation velocity modeling results can be improved.

The present application provides a seismic data processing method, device, computer equipment, storage medium, and product, belonging to the field of seismic exploration technology. The method includes: for each seismic trace, based on the time history information of the seismic trace, the sampling time point corresponding to the time history information and the sampling time point after it are used as the first sampling point of the seismic trace, and the sampling time point before the sampling time point corresponding to the time history information is used as the second sampling point of the seismic trace; based on the signal value of the first sampling point of the seismic trace, the signal value of the second sampling point of the seismic trace is transformed to obtain the first signal value of the second sampling point of the seismic trace; the first signal values ​​of the second sampling points of multiple seismic traces are respectively subjected to gain processing to obtain the second signal values ​​of the second sampling points of multiple seismic traces; for each seismic trace, based on the second signal value of the second sampling point of the seismic trace, the signal value of the first sampling point of the seismic trace is inversely transformed. This method improves the display effect of the vertical seismic profile.

Systems and methods are disclosed. The method includes obtaining vertical seismic profiling (VSP) data and surface seismic (SS) data for a subterranean region of interest. The VSP data includes a corrupt section and a valid section. The method further includes determining a VSP attribute and a VSP spectrum using the VSP data, determining an SS attribute using the SS data, and determining a corrected VSP attribute for the corrupt section. The method still further includes training a neural network using the VSP attribute, the SS attribute, and the VSP spectrum for the valid section, predicting a corrected VSP spectrum for the corrupt section by inputting the corrected VSP attribute and the SS attribute for the corrupt section into the trained neural network, and determining corrected VSP data for the corrupt section using the corrected VSP attribute and the corrected VSP spectrum.

This application provides a method for estimating the quality factor of a target stratum by combining distributed acoustic sensing vertical seismic profile data and surface seismic data, belonging to the field of seismic signal processing technology. The method includes: acquiring distributed acoustic sensing vertical seismic profile data, surface seismic data, and a velocity model of the target stratum; performing DAS-VSP first-arrival ray tracing on the velocity model to obtain the propagation path information of the seismic waves; performing local time-frequency transformation on the direct wave information and calculating the logarithmic spectral ratio slope of the direct wave and the source wavelet; calculating the tectonic dip field of the target stratum based on the surface seismic data; constructing a set of quality factor spectral ratio tomographic equations based on the propagation path information and the logarithmic spectral ratio slope; constructing a regularization term for the Seislet transform based on the tectonic dip field, and establishing a quality factor inversion equation based on the regularization term and the quality factor spectral ratio tomographic equations; and solving the quality factor inversion equations to obtain the quality factor field of the target stratum.